US5758539A - Logging method and system for measuring mechanical parameters of the formations crossed through by a borehole - Google Patents

Logging method and system for measuring mechanical parameters of the formations crossed through by a borehole Download PDF

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US5758539A
US5758539A US08/716,302 US71630296A US5758539A US 5758539 A US5758539 A US 5758539A US 71630296 A US71630296 A US 71630296A US 5758539 A US5758539 A US 5758539A
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uphole
acceleration
representative
acoustic impedance
seismic
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Charles Naville
Jean Guesnon
Claude Mabile
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IFP Energies Nouvelles IFPEN
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/003—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by analysing drilling variables or conditions
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01H—MEASUREMENT OF MECHANICAL VIBRATIONS OR ULTRASONIC, SONIC OR INFRASONIC WAVES
    • G01H15/00—Measuring mechanical or acoustic impedance
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging

Definitions

  • the present invention relates to a method of geological exploration of the drilled formations by the obtaining of measurements substantially comparable to the acoustic impedance of the formations crossed through by the borehole.
  • Measurements are obtained from an acceleration detector placed in the drill string between the rock-breaking bit and mechanical uncoupling means arranged between certain elements of the string.
  • Suitable means for processing the unprocessed acceleration measurements allow the measuring results to be exploited after processing in a way that is similar to the exploitation of a log provided by a conventional "sonic" logging tool, possibly coupled with another logging tool, for example for measuring the density of the formation.
  • the present invention thus relates to a method of geological exploration of the formations drilled by a drill bit fastened to the end of a drill string, said string comprising measuring means delivering a signal representative of the acceleration created by said bit.
  • Mechanical uncoupling means are placed in the drill string, said measuring means are set between said drill bit and said uncoupling means, and a measurement representative of the acoustic impedance of the drilled formations is obtained by processing said signal by a function of the rotating speed of the bit and of the depth.
  • the acceleration measurement can be considered in a time window ranging between 5 and 30 s, and said processing can notably consist:
  • the means for measuring the acceleration can include at least one accelerometer placed so as to measure a signal representative of the axial acceleration, i.e. substantially along the axis of the borehole.
  • the means for measuring the acceleration can include at least one accelerometer placed so as to measure a signal representative of the rotational acceleration. They can include at least one accelerometer placed so as to measure a signal representative of the flexural acceleration. Said accelerometers can have at any time a known orientation in space.
  • Changes in the nature of the drilled formations can be determined from the variations of said measurement representative of the acoustic impedance.
  • Changes in the pore pressure of the drilled formations can be deduced from the variations of said measurement representative of the acoustic impedance.
  • Seismic pickups can be placed at the surface, from which seismic uphole times can be deduced, the source being the noise of the drill bit, for example of the tricone type.
  • a synthetic seismic response in uphole two-way time can be calculated from said measurement representative of the acoustic impedance and said uphole times.
  • the invention further relates to a system of geological exploration of formations drilled by a drill bit fastened to the end of a drill string, said string comprising means for measuring a signal representative of an acceleration created by said bit.
  • the system includes mechanical uncoupling means, measuring means placed between the drill bit and said uncoupling means, and means for processing the signal representative of the bit acceleration and delivered by said measuring means.
  • the measuring and/or processing means can include memories for storing the signals.
  • the uncoupling means can uncouple mechanically the axial motions of the lower part of the drill string from the upper part of the string.
  • the uncoupling means can uncouple mechanically the rotating motions of the lower part of the string from the upper part of the string.
  • the system can include means for sending to the ground surface at least part of the signal representative of the bit acceleration.
  • FIG. 1 diagrammatically shows the measurement acquisition architecture according to an embodiment of the present invention
  • FIG. 2 shows a log of the unprocessed signal EBF provided by an axial acceleration detector
  • FIG. 3 shows the log of the rotating speed of the drill bit
  • FIG. 4 shows the log of the measurement according to the invention, after compensation and smoothing
  • FIG. 5 shows by way of comparison, on the same formation interval, an acoustic impedance log provided by conventional logging tools
  • FIG. 6 diagrammatically shows different transmission means.
  • FIG. 1 shows a borehole 1 in the process of being drilled by means of the drill string 2.
  • String 2 is fastened to the pipe hook by means of the swivel 3, of the kelly 4.
  • Kelly 4 is screwed onto a drillpipe string 5 at the end of which is assembled the bottomhole assembly 6 ended with the drill bit 7.
  • a drilling fluid is injected into the inner space of the string through the flexible tube 8 connected to pumps. The fluid flows out of the string through the nozzles of bit 7, then it flows back towards the ground surface by carrying along the drill cuttings in the annular space 9 defined by the outside of the string and the walls of borehole 1.
  • the advance of the drill bit is achieved by bringing the bit into rotation according to the rotary system, by means of the whole of the drill string that is driven into rotation, either by the rotary table 10 and kelly 4, or by a swivel 3 of the power swivel type.
  • the bit can also be brought into rotation by means of a hydraulic downhole motor, the bit being fastened to the rotor thereof.
  • the bottomhole assembly 6, commonly referred to as "BHA”, comprises measuring means 11 including at least detectors for measuring the acceleration induced by the rock breaking work of the drill bit.
  • accelerations can be measured by at least one accelerometer situated in a specific sub.
  • Such a use of an accelerometer is notably illustrated by documents U.S. Pat. No. 5,226,332 and FR-92/02,273.
  • a mechanical uncoupling system 12 is placed in the bottomhole assembly above measuring means 11, so that the longitudinal (along the axis of the string) or the transverse vibrations created by the bit are mechanicallv uncoupled from the part of the string consisting of the drillpipes 5 and the bottomhole assembly located above uncoupling means 12.
  • the purpose of the uncoupling means is to suppress or at least to limit the phenomena related to the drillpipe string dynamics, notably to the parasitic resonance or reflection vibrations.
  • the uncoupling means can be known devices such as shock absorbers that are used by drill men for filtering the vertical motions created by the drill bit. These devices allow the bit to be driven into rotation by the drill string and they comprise longitudinal buffers in the form of metallic or elastic, notably elastomer springs. It is well-known that certain shock absorbers also have a damping effect on the motion of rotation, in particular those made from elastomer connecting the lower part of the buffer to the upper part. In fact, the latter also damp the rotational vibrations on top of the longitudinal vibrations, the elastomer transmitting the torque between the upper part and the lower part.
  • shock absorbers also have a damping effect on the motion of rotation, in particular those made from elastomer connecting the lower part of the buffer to the upper part. In fact, the latter also damp the rotational vibrations on top of the longitudinal vibrations, the elastomer transmitting the torque between the upper part and the lower part.
  • Bumper subs can also be used as mechanical uncoupling means.
  • the bumper sub consists of a male part that slides in a female part, the length of the male part being so adapted that the sliding length is at least about 1 meter (3 feet).
  • the male and female parts are connected in rotation by a system of keys in grooves so that the rotation of the whole of the string can be transmitted to the drill bit.
  • the bumper sub must not be in an upper or lower extreme position. In this case, there is a mechanical uncoupling between what is placed below and above the bumper sub. Of course, this means that the weight on bit is then limited to the mass of the elements screwed below the bumper sub.
  • the device according to the invention can comprise first measurement processing and acquisition means 13 next to the measuring means 11, and preferably in the same sub.
  • These first means manage the detectors and their power supply, and they preferably deliver a signal by calculating an effective amplitude in a time window ranging between 5 and 30 s.
  • the so-called "effective" amplitude can be the square root of the autocorrelation peak of the acceleration along the same axis.
  • Another equivalent statistical estimator can consist in taking the mean of the absolute values of the signal in said window. This preprocessed signal is representative of the effective acceleration along the axis of measurement of the detectors.
  • any other estimator can be used without departing from the scope of the present invention.
  • the curves of FIGS. 2, 3, 4 and 5 are plotted on a graph having the depth in meter, here the interval between 800 m and 950 m, as the abscissa and the amplitude of the signal as the ordinate.
  • FIG. 2 shows such a signal (EBF) representative of the axial acceleration while drilling between about 800 m and 950 m in depth.
  • EMF signal
  • FIG. 3 shows a log of the rotating speed while drilling in the same interval.
  • the rotating speed recorded is the rotating speed of the rotary table.
  • the true rotating speed of the bit could be exploited by measuring it or by deducing it from measuring detectors placed next to the drill bit.
  • the signal EBF is compensated by dividing signal EBF by the rotating speed and mutliplying by a function of the form:
  • Pf is the bottomhole pressure, therefore a function of the vertical depth of the borehole and of the density of the fluid, a and b being constants related to the borehole environment, particular tectonics, abnormal pressures, type of shock absorber, BHA, . . .
  • EBF can also possibly be divided by the rate of penetration raised to a power close to 0.1.
  • the rate of penetration is a measurement that is always available on a drill rig, for example by measuring the vertical displacement of the block, then by integrating with respect to time.
  • FIG. 5 shows the calculation of the acoustic impedance of the formations crossed through by the borehole in the interval considered, i.e. 800-950 m.
  • This recording is obtained by a "Sonic" type acoustic log that gives the velocity Vp of the compressional waves.
  • This logging of a well-known type is generally performed in the form of a wireline logging, i.e. with a tool lowered into the hole at the end of a cable, the drill string being out of the hole. Together with the use of a "sonic" tool, it is a common procedure to operate at the same time a tool giving the density of the formations crossed, for example a Gamma-Gamma radiation tool.
  • the log of FIG. 5 shows the product of Vp by the density, i.e. the acoustic impedance of the formations.
  • the present invention thus allows to obtain acoustic impedance values from the signal delivered by an accelerometer, said signal being compensated in a simple and determined way according to the present example.
  • the procedure for implementing the system according to the invention depends on the measurement transmission means.
  • FIG. 6 schematizes the main configurations of the transmission of the signal to the surface.
  • Three geographic zones are represented by braces F, T and S.
  • F represents the bottomhole, in the neighbourhood of the drill bit, T the transmission zone, intermediate between bottomhole F and the surface zone S where knowledge of the acoustic impedance measurement is useful.
  • Square EBF represents the acceleration detectors, their management and supply means.
  • Arrows 20, 21, 22 respectively directed towards squares MWD, M and C, represent the electric links in three transmission instances.
  • Square MWD symbolizes a means for processing and for coding the signal EBF, compensated or not, averaged or not, to be transmitted to the surface by pressure waves or by electromagnetic waves. Such a technique is now well known in the profession.
  • Square M symbolizes a memory for storing values EBF, compensated or not.
  • signals EBF are stored downhole.
  • the drill man After drilling the interval, the drill man performs a memory unloading operation by lowering a connector into the drill string at the end of a cable, by connecting it onto a complementary connector linked with the memory, then by pulling up the cable and the connector once the memory has been dumped by means of the electric link.
  • the measurements are thereafter processed at the surface.
  • Square C symbolizes electronic means, for example amplification, coding or multiplexing means, said means being connected to the surface by a continuous conductor.
  • the continuous line can consist of cabled drillpipes, of a cable coaxial to the drill string, or of both in a mixed configuiration. Such a transmission is illustrated in documents FR-92/02,273 or EP-A-526,293.
  • the logging provided by the present invention is a complement to the mud loggings that are already available, such as the rate of penetration, the torque about the drill bit, the pressure, the analysis of the cuttings or of the gases present in the mud.
  • Drilling safety can be increased by the more reliable detection of zones with an abnormal pore pressure, for example the transition zones of cap rocks or of shallow gases.

Abstract

The present invention relates to a method for obtaining a recording or log of measurements substantially comparable to the acoustic impedance of the formations crossed through by the borehole. The measurements are obtained from an acceleration detector (11) placed in the drill string (2) between the rock-breaking bit (7) and mechanical uncoupling system (12) set between certain elements of the string. A measurement representative of the acoustic impedance of the drilled formations is obtained by processing the signal by a function of the rotating speed of the drill bit and of the depth.

Description

SUMMARY OF THE INVENTION
The present invention relates to a method of geological exploration of the drilled formations by the obtaining of measurements substantially comparable to the acoustic impedance of the formations crossed through by the borehole.
Measurements are obtained from an acceleration detector placed in the drill string between the rock-breaking bit and mechanical uncoupling means arranged between certain elements of the string. Suitable means for processing the unprocessed acceleration measurements allow the measuring results to be exploited after processing in a way that is similar to the exploitation of a log provided by a conventional "sonic" logging tool, possibly coupled with another logging tool, for example for measuring the density of the formation.
The present invention thus relates to a method of geological exploration of the formations drilled by a drill bit fastened to the end of a drill string, said string comprising measuring means delivering a signal representative of the acceleration created by said bit. Mechanical uncoupling means are placed in the drill string, said measuring means are set between said drill bit and said uncoupling means, and a measurement representative of the acoustic impedance of the drilled formations is obtained by processing said signal by a function of the rotating speed of the bit and of the depth.
The acceleration measurement can be considered in a time window ranging between 5 and 30 s, and said processing can notably consist:
in calculating in this window an effective amplitude representative of said acceleration signal,
in dividing said amplitude by the rotating speed of the bit, and possibly by the rate of penetration raised to a power close to 0.1,
and in multiplying by a function of the form aPf+b, where a and b are constants related to the borehole environment, notably the depth, and Pf is the bottomhole pressure.
The means for measuring the acceleration can include at least one accelerometer placed so as to measure a signal representative of the axial acceleration, i.e. substantially along the axis of the borehole.
The means for measuring the acceleration can include at least one accelerometer placed so as to measure a signal representative of the rotational acceleration. They can include at least one accelerometer placed so as to measure a signal representative of the flexural acceleration. Said accelerometers can have at any time a known orientation in space.
Changes in the nature of the drilled formations can be determined from the variations of said measurement representative of the acoustic impedance.
Changes in the pore pressure of the drilled formations can be deduced from the variations of said measurement representative of the acoustic impedance.
Seismic pickups can be placed at the surface, from which seismic uphole times can be deduced, the source being the noise of the drill bit, for example of the tricone type. In the method, a synthetic seismic response in uphole two-way time can be calculated from said measurement representative of the acoustic impedance and said uphole times.
The invention further relates to a system of geological exploration of formations drilled by a drill bit fastened to the end of a drill string, said string comprising means for measuring a signal representative of an acceleration created by said bit. The system includes mechanical uncoupling means, measuring means placed between the drill bit and said uncoupling means, and means for processing the signal representative of the bit acceleration and delivered by said measuring means. The measuring and/or processing means can include memories for storing the signals.
The uncoupling means can uncouple mechanically the axial motions of the lower part of the drill string from the upper part of the string.
The uncoupling means can uncouple mechanically the rotating motions of the lower part of the string from the upper part of the string.
The system can include means for sending to the ground surface at least part of the signal representative of the bit acceleration.
BRIEF DESCRIPTION OF THE DRAWINGS
Other features and advantages of the invention will be clear from reading the description hereafter of embodiments given by way of non limitative examples, with reference to the accompanying drawings in which:
FIG. 1 diagrammatically shows the measurement acquisition architecture according to an embodiment of the present invention,
FIG. 2 shows a log of the unprocessed signal EBF provided by an axial acceleration detector,
FIG. 3 shows the log of the rotating speed of the drill bit,
FIG. 4 shows the log of the measurement according to the invention, after compensation and smoothing,
FIG. 5 shows by way of comparison, on the same formation interval, an acoustic impedance log provided by conventional logging tools,
FIG. 6 diagrammatically shows different transmission means.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
FIG. 1 shows a borehole 1 in the process of being drilled by means of the drill string 2. String 2 is fastened to the pipe hook by means of the swivel 3, of the kelly 4. Kelly 4 is screwed onto a drillpipe string 5 at the end of which is assembled the bottomhole assembly 6 ended with the drill bit 7. A drilling fluid is injected into the inner space of the string through the flexible tube 8 connected to pumps. The fluid flows out of the string through the nozzles of bit 7, then it flows back towards the ground surface by carrying along the drill cuttings in the annular space 9 defined by the outside of the string and the walls of borehole 1.
The advance of the drill bit is achieved by bringing the bit into rotation according to the rotary system, by means of the whole of the drill string that is driven into rotation, either by the rotary table 10 and kelly 4, or by a swivel 3 of the power swivel type. The bit can also be brought into rotation by means of a hydraulic downhole motor, the bit being fastened to the rotor thereof.
According to the invention, the bottomhole assembly 6, commonly referred to as "BHA", comprises measuring means 11 including at least detectors for measuring the acceleration induced by the rock breaking work of the drill bit. As it is known in the profession, accelerations can be measured by at least one accelerometer situated in a specific sub. Such a use of an accelerometer is notably illustrated by documents U.S. Pat. No. 5,226,332 and FR-92/02,273. For the measurements acquired thereby to be exploitable according to the present invention, a mechanical uncoupling system 12 is placed in the bottomhole assembly above measuring means 11, so that the longitudinal (along the axis of the string) or the transverse vibrations created by the bit are mechanicallv uncoupled from the part of the string consisting of the drillpipes 5 and the bottomhole assembly located above uncoupling means 12. The purpose of the uncoupling means is to suppress or at least to limit the phenomena related to the drillpipe string dynamics, notably to the parasitic resonance or reflection vibrations.
The uncoupling means can be known devices such as shock absorbers that are used by drill men for filtering the vertical motions created by the drill bit. These devices allow the bit to be driven into rotation by the drill string and they comprise longitudinal buffers in the form of metallic or elastic, notably elastomer springs. It is well-known that certain shock absorbers also have a damping effect on the motion of rotation, in particular those made from elastomer connecting the lower part of the buffer to the upper part. In fact, the latter also damp the rotational vibrations on top of the longitudinal vibrations, the elastomer transmitting the torque between the upper part and the lower part.
Bumper subs can also be used as mechanical uncoupling means. The bumper sub consists of a male part that slides in a female part, the length of the male part being so adapted that the sliding length is at least about 1 meter (3 feet). The male and female parts are connected in rotation by a system of keys in grooves so that the rotation of the whole of the string can be transmitted to the drill bit. During drilling, the bumper sub must not be in an upper or lower extreme position. In this case, there is a mechanical uncoupling between what is placed below and above the bumper sub. Of course, this means that the weight on bit is then limited to the mass of the elements screwed below the bumper sub.
The device according to the invention can comprise first measurement processing and acquisition means 13 next to the measuring means 11, and preferably in the same sub. These first means manage the detectors and their power supply, and they preferably deliver a signal by calculating an effective amplitude in a time window ranging between 5 and 30 s. The so-called "effective" amplitude can be the square root of the autocorrelation peak of the acceleration along the same axis. Another equivalent statistical estimator can consist in taking the mean of the absolute values of the signal in said window. This preprocessed signal is representative of the effective acceleration along the axis of measurement of the detectors. Of course, any other estimator can be used without departing from the scope of the present invention.
The curves of FIGS. 2, 3, 4 and 5 are plotted on a graph having the depth in meter, here the interval between 800 m and 950 m, as the abscissa and the amplitude of the signal as the ordinate.
FIG. 2 shows such a signal (EBF) representative of the axial acceleration while drilling between about 800 m and 950 m in depth.
FIG. 3 shows a log of the rotating speed while drilling in the same interval. In this example, the rotating speed recorded is the rotating speed of the rotary table. In other cases, the true rotating speed of the bit could be exploited by measuring it or by deducing it from measuring detectors placed next to the drill bit.
The signal EBF is compensated by dividing signal EBF by the rotating speed and mutliplying by a function of the form:
aPf+b
where Pf is the bottomhole pressure, therefore a function of the vertical depth of the borehole and of the density of the fluid, a and b being constants related to the borehole environment, particular tectonics, abnormal pressures, type of shock absorber, BHA, . . .
EBF can also possibly be divided by the rate of penetration raised to a power close to 0.1. The rate of penetration, not shown here, is a measurement that is always available on a drill rig, for example by measuring the vertical displacement of the block, then by integrating with respect to time.
Signal EBF, once compensated, is shown in FIG. 4.
FIG. 5 shows the calculation of the acoustic impedance of the formations crossed through by the borehole in the interval considered, i.e. 800-950 m. This recording is obtained by a "Sonic" type acoustic log that gives the velocity Vp of the compressional waves. This logging of a well-known type is generally performed in the form of a wireline logging, i.e. with a tool lowered into the hole at the end of a cable, the drill string being out of the hole. Together with the use of a "sonic" tool, it is a common procedure to operate at the same time a tool giving the density of the formations crossed, for example a Gamma-Gamma radiation tool. The log of FIG. 5 shows the product of Vp by the density, i.e. the acoustic impedance of the formations.
It is clear, by comparing the curves of FIG. 4 and of FIG. 5, that the compensated signal EBF is very close to the acoustic impedance measurement that can be obtained by known means. In particular, the phenomenon between depth points 865 and 870 m is reproduced, as well as the impedance variation of the formations at point 918 m.
The present invention thus allows to obtain acoustic impedance values from the signal delivered by an accelerometer, said signal being compensated in a simple and determined way according to the present example.
The procedure for implementing the system according to the invention depends on the measurement transmission means.
FIG. 6 schematizes the main configurations of the transmission of the signal to the surface. Three geographic zones are represented by braces F, T and S. F represents the bottomhole, in the neighbourhood of the drill bit, T the transmission zone, intermediate between bottomhole F and the surface zone S where knowledge of the acoustic impedance measurement is useful. Square EBF represents the acceleration detectors, their management and supply means. Arrows 20, 21, 22 respectively directed towards squares MWD, M and C, represent the electric links in three transmission instances. Square MWD symbolizes a means for processing and for coding the signal EBF, compensated or not, averaged or not, to be transmitted to the surface by pressure waves or by electromagnetic waves. Such a technique is now well known in the profession. The rate of information to be transmitted is compatible with the capacity of such a system. Square M symbolizes a memory for storing values EBF, compensated or not. During a given drilling interval, signals EBF are stored downhole. After drilling the interval, the drill man performs a memory unloading operation by lowering a connector into the drill string at the end of a cable, by connecting it onto a complementary connector linked with the memory, then by pulling up the cable and the connector once the memory has been dumped by means of the electric link. The measurements are thereafter processed at the surface. Square C symbolizes electronic means, for example amplification, coding or multiplexing means, said means being connected to the surface by a continuous conductor. The continuous line can consist of cabled drillpipes, of a cable coaxial to the drill string, or of both in a mixed configuiration. Such a transmission is illustrated in documents FR-92/02,273 or EP-A-526,293.
Simplified knowledge of the acoustic impedance of formations in the process of being drilled is interesting for deducing the nature of the rocks that are drilled by the bit. Changes in the formations can thus be detected during drilling by observing variations in the impedance of the formations. The logging provided by the present invention is a complement to the mud loggings that are already available, such as the rate of penetration, the torque about the drill bit, the pressure, the analysis of the cuttings or of the gases present in the mud.
Drilling safety can be increased by the more reliable detection of zones with an abnormal pore pressure, for example the transition zones of cap rocks or of shallow gases.

Claims (21)

We claim:
1. A method of geological exploration of formation comprising drilling a borehole to a depth into the formation, said drilling being conducted by a drill bit (7) fastened to the end of a drill string (2), said string comprising measuring means (11) delivering a signal representative of an acceleration created by said bit, wherein mechanical uncoupling means (12) are placed in the drill string, said measuring means are set between said drill bit (7) and said uncoupling means (12), and a measurement representative of the acoustic impedance of the drilled formation is obtained by processing said signal by a function of the rotating speed of the drill bit and of the depth of the borehole.
2. A method as claimed in claim 1, wherein the acceleration measurement is considered in a time window ranging between 5 and 30 s, said processing comprising:
calculating in this window an effective amplitude representative of said acceleration signal,
dividing said amplitude by the rotating speed of the drill bit, and optionally by the rate of penetration raised to a power of about 0.1,
and multiplying said amplitude by aPf+b, where a and b are constants related to the borehole environment, notably the depth, and Pf the bottomhole pressure.
3. A method as claimed in claim 2, wherein the acceleration measuring means (11) comprises at least one accelerometer placed so as to measure a signal representative of the axial acceleration substantially, along the axis of the borehole.
4. A method as claimed in claim 2, wherein pore pressure changes in the drilled formations are deduced from variations in said measurement representative of the acoustic impedance.
5. A method as claimed in claim 4, wherein seismic pickups from which seismic uphole times are deduced are placed at the surface, the source being the noise of the drill bit, characterized in that a synthetic seismic response in uphole two-way time is calculated from said measurement representative of the acoustic impedance and said uphole times.
6. A method of claim 2, wherein seismic pickups from which seismic uphole times are deduced are placed at the surface, the source being the noise of the drill bit, characterized in that a synthetic seismic response in uphole two-way time is calculated from said measurement representative of the acoustic impedance and said uphole times.
7. A method as claimed in claim 2, wherein acceleration measuring means comprises at least one accelerometer placed so as to measure a signal representative of the rotation acceleration.
8. A method as claimed in claim 1, wherein the acceleration measuring means (11) comprises at least one accelerometer placed so as to measure a signal representative of the axial acceleration, substantially along the axis of the borehole.
9. A method of claim 8, wherein seismic pickups from which seismic uphole times are deduced are placed at the surface, the source being the noise of the drill bit, characterized in that a synthetic seismic response in uphole two-way time is calculated from said measurement representative of the acoustic impedance and said uphole times.
10. A method as claimed in claim 8, wherein acceleration measuring means comprises at least one accelerometer placed so far as to measure a signal representative of the rotation acceleration.
11. A method as claimed in claim 8, wherein pore pressure changes in the drilled formations are deduced from variations in said measurement representative of the acoustic impedance.
12. A method as claimed in claim 1, wherein the acceleration measuring means comprise at least one accelerometer placed so as to measure a signal representative of the rotational acceleration.
13. A method as claimed in claim 1, wherein changes in the nature of the drilled formations are determined from variations in said measurement representative of the acoustic impedance.
14. A method as claimed in claim 1, wherein pore pressure changes in the drilled formations are deduced from variations in said measurement representative of the acoustic impedance.
15. A method of claim 14, wherein seismic pickups from which seismic uphole times are deduced are placed at the surface, the source being the noise of the drill bit, characterized in that a synthetic seismic response in uphole two-way time is calculated from said measurement representative of the acoustic impedance and said uphole times.
16. A method as claimed in claim 1, wherein seismic pickups from which seismic uphole times are deduced are placed at the surface, the source being the noise of the drill bit, characterized in that a synthetic seismic response in uphole two-way time is calculated from said measurement representative of the acoustic impedance and said uphole times.
17. A method as claimed in claim 1, wherein the acceleration measurement is considered in a time window ranging between 5 and 30 s, said processing comprising:
calculating in this window an effective amplitude representative of said acceleration signal,
dividing said amplitude by the rotating speed of the drill bit and by the rate of penetration raised to a power of about to 0.1,
and multiplying said amplitude by aPf+b, where a and b are constants related to the borehole environment, notably the depth, and Pf the bottomhole pressure.
18. A method as claimed in claim 17, wherein the acceleration measuring means (11) comprises at least one accelerometer placed so as to measure a signal representative of the axial acceleration, substantially, along the axis of the borehole.
19. A method as claimed in claim 17, wherein pore pressure changes in the drilled formations are deduced from variations in said measurement representative of the acoustic impedance.
20. A method as claimed in claim 17, wherein seismic pickups from which seismic uphole times are deduced are placed at the surface, the source being the noise of the drill bit, characterized in that a synthetic seismic response in uphole two-way time is calculated from said measurement representative of the acoustic impedance and said uphole times.
21. A method as claimed in claim 17, wherein acceleration measuring means comprises at least one accelerometer placed so as to measure a signal representative of the rotation acceleration.
US08/716,302 1995-01-25 1996-01-23 Logging method and system for measuring mechanical parameters of the formations crossed through by a borehole Expired - Lifetime US5758539A (en)

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FR95/00938 1995-01-25
FR9500938A FR2729708A1 (en) 1995-01-25 1995-01-25 METHOD AND SYSTEM FOR DIAGRAPHING MECHANICAL PARAMETERS OF LANDS CROSSED BY A BOREHOLE
PCT/FR1996/000105 WO1996023127A1 (en) 1995-01-25 1996-01-23 Method and system for logging mechanical parameters of formations crossed through by a borehole

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US6023444A (en) * 1995-12-22 2000-02-08 Institut Francais Du Petrole Method and device for the acquisition of signals while drilling
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US20040059511A1 (en) * 2000-10-10 2004-03-25 Exxonmobil Upstream Research Company Method for borehole measurement of formation properties
US20040162676A1 (en) * 2000-10-10 2004-08-19 Exxonmobil Upstream Research Company Method for borehole measurement of formation properties
US7289909B2 (en) 2000-10-10 2007-10-30 Exxonmobil Upstream Research Company Method for borehole measurement of formation properties
US7310580B2 (en) 2000-10-10 2007-12-18 Exxonmobil Upstream Research Company Method for borehole measurement of formation properties
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EP1730663A4 (en) * 2004-03-04 2012-12-19 Halliburton Energy Serv Inc Providing a local response to a local condition in an oil well
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US20060076161A1 (en) * 2004-10-07 2006-04-13 Gary Weaver Apparatus and method of identifying rock properties while drilling
US20070280048A1 (en) * 2006-06-06 2007-12-06 Baker Hughes Incorporated P-wave anisotropy evaluation by measuring acoustic impedance of the rock by beam-steering from within the borehole at different angles
WO2008030285A3 (en) * 2006-06-06 2009-02-12 Baker Hughes Inc P-wave anisotropy evaluation by measuring acoustic impedance of the rock by beam-steering from within the borehole at different angles
US7626886B2 (en) 2006-06-06 2009-12-01 Baker Hughes Incorporated P-wave anisotropy determination using borehole measurements
GB2452452B (en) * 2006-06-06 2011-03-09 Baker Hughes Inc P-Wave anisotropy evaluation by measuring acoustic impedance of the rock by beam steering from within the borehole at different angles
WO2008030285A2 (en) * 2006-06-06 2008-03-13 Baker Hughes Incorporated P-wave anisotropy evaluation by measuring acoustic impedance of the rock by beam-steering from within the borehole at different angles
US20100246325A1 (en) * 2009-03-03 2010-09-30 Baker Hughes Incorporated Method and Apparatus for Acoustic Impedance and P-Wave Anisotropy Measurements
US8576659B2 (en) 2009-03-03 2013-11-05 Baker Hughes Incorporated Method and apparatus for acoustic impedance and P-wave anisotropy measurements
US8087477B2 (en) * 2009-05-05 2012-01-03 Baker Hughes Incorporated Methods and apparatuses for measuring drill bit conditions
US20100282510A1 (en) * 2009-05-05 2010-11-11 Baker Hughes Incorporated Methods and apparatuses for measuring drill bit conditions
CN102562049A (en) * 2011-11-14 2012-07-11 上海神开石油化工装备股份有限公司 Method for predicting change of strata while drilling
US20130118807A1 (en) * 2011-11-15 2013-05-16 Saudi Arabian Oil Company Methods For Geosteering A Drill Bit In Real Time Using Drilling Acoustic Signals
WO2013074765A3 (en) * 2011-11-15 2013-08-15 Saudi Arabian Oil Company Methods for geosteering a drill bit in real time using surface acoustic signals
US9103192B2 (en) * 2011-11-15 2015-08-11 Saudi Arabian Oil Company Methods for geosteering a drill bit in real time using drilling acoustic signals
US9334723B2 (en) 2011-11-15 2016-05-10 Saudi Arabian Oil Company Methods for geosteering a drill bit in real time using surface acoustic signals

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WO1996023127A1 (en) 1996-08-01
CA2186402A1 (en) 1996-08-01
FR2729708A1 (en) 1996-07-26
EP0836670A2 (en) 1998-04-22
NO964017L (en) 1996-09-25
EP0836670B1 (en) 2002-09-18
FR2729708B1 (en) 1997-03-07
NO964017D0 (en) 1996-09-24

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